odisha power sector and tariff for fy 2012-13 · 2012-04-26 · odisha power sector and tariff for...
TRANSCRIPT
Odisha Power Sector and Tariff for FY 2012-13
1. Consumers as on Sept. 2011
CONSUMERS (As on Sept. 2011)
CESU NESCO WESCO SOUTHCO TOTAL
EHT 22 30 24 12 88 HT 1181 379 633 185 2378 LT 1362839 764769 696815 799475 3623898 Total 1364042 765178 697472 799672 3626364
• Per capita consumption of electricity per year (2009-10) – 874.24 Kwh
(All India average 778.71 Kwh.)
2. Installed Capacity in Odisha as on Sept. 2011 ( 4756 MW)
• Total installed capacity 4756 MW (Hydro 2331 MW + Thermal 2425 MW) • State Hydro (OHPC) 2085 MW
(Odisha share from Machhkund 57 MW + 2028 MW) • Small Hydro 57 MW
------------- Sub total of State Hydro sector 2142 MW State Thermal Power Stations 880 MW (Ib thermal OPGC 420 MW+ Talcher
Thermal NTPC 460 MW)
IPPs (SEL& Arati) 650MW • Sub total of State Sector 3672 MW (Hydro 2142 MW + Thermal 1530MW)
• Central Sector 1084 MW (Thermal 895 MW + Hydro 189 MW)
• Total Capacity 4756 MW ( Hydro 2331 MW + Thermal 2425 MW)
2
Availability of Power From Existing Stations
INSTALLED CAPACITY & NORMATIVE ENERGY AVAILABILITY OF ODISHA
GENERATING STATIONS
CAPACITY DETAILS (NOS.
x MW)
Odisha Share Ex-bus availability
to GRIDCO
(MU)
REMARKS Actual for
2010-11 (Audited) % MW MU
STATE STATIONS
HYDRO (OHPC)
HIRAKUD
2*49.5+2*32+3*37.5+3* 24 (Chipilima)
100.00 348 1,174.0
1,162.3
Design Energy less Auxulary
Consumption (AC) @ 1%
905.31
BALIMELA 6*60+2*75 100.00 510 1,183.0
1,171.2 1,261.86
U.KOLAB 4*80 100.00 320 832.0
823.7 553.11
RENGALI 5*50 100.00 250 525.0
519.8 253.12
INDRAVATI 4*150 100.00 600 1,962.0
1,942.4 1,632.50
Sub Total 2,028 5,676 5,619 4,605.90
MACHAKUND (3*17+3*21.25)=114.75MW
50.00 57 262.5
262.5 Assuming Orissa drawal of 50% energy 268.44
TOTAL HYDRO 2,085 5,939
5,882 4,874.34
SMALL HYDRO
SAMAL S H P (OPCL) 5 * 4
100.00 20 114 113
Design Energy less Auxulary
Consumption (AC) @ 1%
249.73 MEENAKSHEE HEP 2*12.5+3*4
100.00 37 142 140
TOTAL STATE HYDRO 2,142 6,194
6,135 5,124.07
THERMAL
IBTPS 2*210 100.00 420 3,127
2,830
Considering PLF of 85% and Aux. Consumption at 9.5%
2,843.40
TTPS 2*110+4*60 100.00 460 3,304
2,957
Considering PLF of 82% and Aux. Consumption at 10.5%
3,374.97
IPPs
M/s Staerilite Energy
600.00 600 4,205
3,784 Considering PLF of 80% and Aux. Consumption at 10% 845.61
Arati Steels
50.00 50 350 315
Considering PLF of 80% and Aux. Consumption at 10%
3
TOTAL STATE THERMAL 1,530 10,987
9,887 7,063.98
STATE TOTAL 3,672 17,181 16,022 12,188.05
CENTRAL STATIONS
Central Transmission Loss (CTL) of 2.3% considered as per ARR Order
for FY2011-12
HYDRO
CHUKHA 4*84=336 Availability to ER-270
15.19% 41 283.3 273.4
Based on Past trend and parameters
taken in the ARR of GRIDCO for FY2011-
12
278.49
TALA 6 * 170=1020 4.25% 43 151.3 143.2 151.56
TEESTA 3 * 170= 510 20.59% 105 529.6 511.3
Design Energyof 2573MU less Auxulary Consumption (AC) @ 1.2% & CTL @ 2.3%
532.00
TOTAL CENTRAL
HYDRO 189 964.2
927.8 962.05
THERMAL
FSTPS 3*200+2*500=1600
13.63% 218 1,623.2 1,475.8
PLF of 85% , Aux. Cons. at 6.94% & CTL @ 2.3%
1,550.92
TSTPS - I 2*500=1000 31.80% 318 2,367.8 2,163.0
PLF of 85% , Aux. Cons. at 6.5% & CTL @ 2.3%
2,207.97
TSTPS - II 4*500=2000 10.00% 200 1,489.2 1,360.4
PLF of 85% , Aux. Cons. at 6.5% & CTL @ 2.3%
1,474.44
KHSTPS - I 4*210=840 15.24% 128 953.1 847.4
PLF of 85% , Aux. Cons. at 9.0% & CTL @ 2.3%
766.29
KHSTPS - II 3*500=1500 2.05% 31 230.8 210.9
PLF of 85% , Aux. Cons. at 6.5% & CTL @ 2.3%
173.10
TOTAL CENTRAL THERMAL
895 6,664.2 6,057.4 6,192.72
SUB TOTAL CENTRAL SECTOR
1,084 7,628.4 6,985.3
% of State Hydro to Total availability
7,134.77
TOTAL (CENTRAL+ST
ATE) 4,756 24,809.1 23,007.1 30.7% 19,322.08
CGP & Co-Generation 3,013.67
UI Over Drawal 554.32
Power Banking & Trading -21.83
TOTAL 22,868.98
4
3. State Demand and Energy Procurement (Energy in MU)
2008-09 2009-10 2010-11 Energy Requirement 20,519 21,136 22,506 Energy Supplied 20,214 20,955 22,449 Deficit(-)/Surplus (+) (-)1.5% (-)0.9% (-)0.3%
(Demand in MW)
2008-09 2009-10 2010-11 Peak Demand 3,062 3,188 3,872 Peak Demand met 2,987 3,120 3,792 Deficit(-)/Surplus (+) (-)2.4% (-)2.2% (-)2.1%
Source :CEA LGBR
The Report of 17th Electric Power Survey (EPS) of India published by CEA in March,
2007 made the forecast for the power demand of Odisha for 11th, 12th & 13th Plan as
shown in Table below:-
FY 2011-12 (End of
11th Plan)
2012-13
2013-14
2014-15
2015-16
2016-17 (End of
12th Plan)
2021-22 (End of
13th Plan)
Remarks
Peak Demand (MW) 4459 4783 5130 5502 5902 6330 10,074
As per Table 6.4 of 17th EPS of CEA, Energy Requirement and Peak Demand have been computed for 12th Plan @ 7.57% and 7.26% respectively.
Energy Requirement (MU)
27149 29204 31415 33793 36351 39096 63,098
Installed Capacity Required (MW) 6670 7154 7687 8245 8828 9469 15,069
GRIDCO and OPTCL have submitted before the Commission that PRDC, Bangalore made a study
by Monte-Carlo Simulation Method as well as by Analytical Method to assess the quantum of
surplus power during the terminal year of 11th Plan i.e. during FY 2011-12 and during 12th Plan
period based on the forecast of demand made by OPTCL as well as in 17th EPS of CEA mentioned
above and submitted their Report to GRIDCO in August, 2011 which observes as under:
“Odisha State will not be surplus up to FY 2015-16 and Odisha Power Sector would witness a surplus scenario from FY 2016-17 onwards.”
The Commission has analysed the emerging power scenario of Odisha during 12th Plan as shown in
table below:
Emerging Scenario of deficit/surplus of power during FY 2011-12 & 12th Plan period
5
(All in MW)
FY Peak Demand as per 17th EPS of CEA
Maximum Peak Demand that can be met
Deficit(-)/Surplus(+)
2011-12 4459 3125 (-)1334
2012-13 4783 3650 (-)1133
2013-14 5130 4050 (-)1080
2014-15 5502 4200 (-)1302
2015-16 5902 5880 (-) 22
2016-17 6330 9768 (+)3438
4. Power Procurement from CGPs Including Co-generation
Supply of surplus power by CGPs/Co-generation/ SHEP: Total installed Capacity: (Grid Connected) 4454 MW No of CGPs supplying surplus power: to GRIDCO 27 Nos.
Availability of power from CGPs: 300 MW Average Power procured from CGPs: As given in table below:
Year CGP(MU) Co-Gen (MU) Total (MU) Average Rate Rs./KWH
2005-06 475.34 75.01 550.35 1.17
2006-07 628.42 165.72 794.14 1.59
2007-08 381.60 354.45 736.05 1.88
2008-09 712.40 479.91 1192.31 2.29
2009-10 2295.48 671.61 2967.09 3.18
2010-11 2240.08 781.15 3021.23 2.91
Rate of procurement of power:
From : 01-11-2009
CGP: Rs. 3.10/3.40/3.70/4.05 per Unit Co-generation: Rs. 3.20/3.40/3.70/4.05 per Unit
From : 10-11-2010 to 31.03.2011 and continuing till date Both for CGP and Co-generation:
100% Supply to GRIDCO Rs. 2.75/3.10/3.25 per Unit
60% Supply to GRIDCO Rs. 2.75/3.00/3.20 per Unit
GRIDCO Drawal from CGPs & Co-generation Plants (Provisional)
Sl. No.
Name of CGPs & Co-generation
Plants
Installed Capacity
(MW)
2006-07 (Audited) 2007-08(Audited) 2008-09 (Audited) 2009-10 (Provisional) 2010-11 (Provisional)
Energy (MU)
Cost (Rs.in
Cr)
Avg. Rate Rs./KWH
Energy (MU)
Cost (Rs.in
Cr)
Avg. Rate Rs./KWH
Energy (MU)
Cost (Rs.in Cr)
Avg. Rate
Rs./KWH
Energy (MU)
Cost (Rs.in
Cr)
Avg. Rate
Rs./KWH
Energy (MU)
Cost (Rs.in Cr)
Avg. Rate Rs./KWH
CGPs
1 NALCO 1,080.00 421.62 62.12 1.47 129.52 18.24 1.41 80.28 13.46 1.68 14.57 4.38 3.01 58.31 13.81 2.37
2 ICCL 108.00 19.15 1.80 0.94 3.29 0.31 0.94 42.87 11.99 2.80 187.36 57.31 3.06 47.46 13.69 2.88
3 INDAL(HINDALCO) 367.50 31.36 2.42 0.77 31.77 5.09 1.60 49.22 10.58 2.15 90.87 28.49 3.14 56.22 15.29 2.72
4 RSP 220.00 39.10 2.52 0.64 24.73 1.72 0.70 14.04 1.02 0.73 20.88 1.92 0.92 20.05 2.09 1.04
5 NBVL 95.00 2.14 0.13 0.61 176.00 42.30 2.40 230.77 69.22 3.00 177.68 49.57 2.79
6 Vedanta (jharsuguda) 1,215.00 29.27 6.17 2.11 697.10 242.49 3.48 741.93 240.76 3.25
7 JSL 263.00 23.12 2.90 1.25 280.01 70.08 2.50 874.63 292.87 3.35 916.38 284.12 3.10
8 BHUSAN (S&P) 360.00 115.05 25.11 2.18 169.17 38.28 2.26 35.38 7.40 2.09 97.76 11.51 1.18 112.80 25.18 2.23
9 Rathi Steel & Power 20.00 0.38 0.06 1.58 18.53 5.56 3.00 13.85 2.46 1.78
10 Maheswary 24.00 2.99 0.93 3.11 10.53 2.40 2.28
11 Dinabandhu 10.00 3.56 1.09 3.06 17.17 5.14 2.99
12 OSIL,Palaspanga 36.00 25.04 7.85 3.13 40.38 11.64 2.88
13 SCAW Industries 8.00 4.80 0.88 1.83 10.99 1.93 1.76
14 Shree Mahavir Ferro Alloys 12.00 0.15 0.05 3.33 31.42 9.61 3.06 14.48 3.63 2.51
15 OCL Iron &Steel 14.00 1.41 0.44 3.12
16 Maithan 0.44 0.08 1.82
Sub Total 3832.50 628.42 94.10 1.50 381.60 66.54 1.74 712.40 163.99 2.30 2295.48 733.23 3.19 2240.08 672.23 3.00
7
Sl. No.
Name of CGPs & Co-generation
Plants
Installed Capacity
(MW)
2006-07 (Audited) 2007-08(Audited) 2008-09 (Audited) 2009-10 (Provisional) 2010-11 (Provisional)
Energy (MU)
Cost (Rs.in
Cr)
Avg. Rate Rs./KWH
Energy (MU)
Cost (Rs.in
Cr)
Avg. Rate Rs./KWH
Energy (MU)
Cost (Rs.in Cr)
Avg. Rate
Rs./KWH
Energy (MU)
Cost (Rs.in
Cr)
Avg. Rate
Rs./KWH
Energy (MU)
Cost (Rs.in Cr)
Avg. Rate Rs./KWH
Co-Generation Plants
1 NINL 62.50 71.17 14.38 2.02 88.55 17.89 2.02 76.33 17.53 2.30 71.07 22.25 3.13 73.95 20.83 2.82
2 ARATI STEEL 40.00 85.65 17.55 2.05 84.09 18.49 2.20 127.39 29.85 2.34 116.21 35.52 3.06 85.18 23.32 2.74
3 TATA SPONGE 26.00 1.06 0.08 0.75 112.44 25.45 2.26 126.11 29.55 2.34 126.17 37.01 2.93 126.22 35.13 2.78
4 SMC Power 33.00 32.78 6.75 2.06 46.87 15.03 3.21 50.15 13.45 2.68
5 IFFCO,Paradeep 110.00 0.29 0.06 2.07 24.18 7.64 3.16 38.87 11.11 2.86
6 Visa Steel Duburi 50.00 1.97 0.19 0.96 8.60 2.62 3.05 24.57 5.02 2.04
7 VEDANT (Lanjigarh) 90.00 0.25 0.01 0.40 17.45 2.81 1.61 10.32 2.21 2.14 18.96 5.88 3.10 20.24 5.44 2.69
8 SHYAM DRI 30.00 8.89 1.80 2.02 31.02 6.67 2.15 28.78 8.87 3.08 111.44 29.69 2.66
9 BHUSAN (S&S) 110.00 7.59 0.35 0.46 42.74 5.15 1.20 58.80 12.69 2.16 137.95 45.59 3.30 129.62 29.75 2.30
10 Action Ispat 37.00 26.81 8.52 3.18 24.56 6.33 2.58
11 Aryan Ispat 18.00 29.88 9.62 3.22 62.06 17.66 2.85
12 Pattnaik SteeL,Palaspanga 15.00 15.19 3.35 2.21 36.13 11.19 3.10 34.29 9.38 2.74
Sub Total 621.50 165.72 32.37 1.95 354.45 71.65 2.02 479.91 108.79 2.27 671.61 209.74 3.12 781.15 207.11 2.65
TOTAL 4,454.00 794.14 126.47 1.59 736.05 138.19 1.88 1,192.31 272.78 2.29 2,967.09 942.97 3.18 3021.23 879.34 2.91
5. GRIDCO POWER PURCHASE FROM DIFFERNET SOURCES BY GRIDCO
8* Up to December 2011, the Total Rate (P/U) is 210.00
COMMISSION's APPROVAL
FOR 2010-11 ACTUAL FOR 2010-11
(Audited) COMMISSION's APPROVAL FOR
2011-12 ACTUAL FOR 2011-12 (Upto Sept
2011) COMMISSION's APPROVAL FOR
2012-13
Generators Energy
(MU)
Total Rate P/U
Total cost
(Rs.Cr.) Energy
(MU) Total
Rate P/U Total cost (Rs.Cr.)
Energy (MU)
Total Rate P/U
Total cost (Rs.Cr.)
Energy (MU)
Total Rate P/U
Total cost (Rs.Cr.)
Energy (MU)
Total Rate P/U
Total cost (Rs.Cr.)
HYDRO (OLD) 3676.86 58.49 215.06 2973.40 66.94 199..04 3676.86 63.15 232.19 2304.65 57.45 132.40 3676.86 66.05 242.87
Indravati 1942.38 75.59 146.82 1632.50 87.96 143.59 1942.38 77.21 149.97 1012.20 79.27 80.24 1942.38 79.26 153.96
Machakund 262.50 21.95 5.76 268.44 30.62 8.22 262.50 22.06 5.79 100.05 22.09 2.21 262.50 30.51 8.01
Total Hydro 5881.74 62.51 367.65 4874.34 71.98 350.85 5881.74 65.96 387.96 3416.90 62.88 214.85 5881.74 68.83 404.84
OPGC 2853.53 149.04 425.30 2843.40 159.30 452.94 2892.49 179.22 518.39 1295.10 166.00 214.99 2890.82 195.15 564.14
TTPS (NTPC) 2957.32 171.38 506.84 3374.97 166.64 562.41 2957.32 180.50 533.80 1630.39 166.87 272.06 2957.32 179.87 531.94 IPPs (Sterilite Energy ltd & Arati.) 646.23 243.54 157.38 845.61 200.35 169.42 3357.12 275.00 923.21 880.73 257.95 227.18 3556.92 278.91 992.06
Total CGPs 1051.00 325.00 341.58 3013.67 271.48 818.15
603.79 277.76 167.71
857.18 233.61 200.25
696.10 286.21 199.23
Co-Generation Plants 529.00 330.00 174.57 512.46 275.00 140.93 665.76 283.02 188.42
Total State Thermal 8037.08 199.78 1605.66 10,077.65 198.75 2002.92 10323.18 221.25 2284.03 4663.40 196.10 914.48 10766.92 229.94 2475.79
Small Hydro 300.00 305.00 91.50 249.73 414.93 103.62 300.00 320.32 96.10 160.02 320.27 51.25 300.00 368.00 110.40 Renewable Biomass 122.00 501.00 61.12 Renewable Solar 0.31 1838.71 0.57 46.00 517.52 23.81
TOTAL STATE 14218.80 145.22 2064.81 15201.72 161.65 2457.39 16504.92 167.71 2768.08 8240.63 143.33 1181.15 17116.66 179.71 3075.96
CHUKHA 271.79 183.32 49.83 278.49 159.00 44.28 273.36 181.38 49.58 174.52 189.03 32.99 272,90 162.86 44.44
Tala HPS 145.17 209.12 30.36 151.56 184.02 27.89 143.16 206.97 29.63 111.12 214.72 23.86 144.29 206.90 29.85
Teesta-V 507.19 186.42 94.55 532.00 181.02 96.30 511.32 172.17 88.03 340.99 161.88 55.20 510.95 214.44 109.57
Total Central Hydro 924.16 189.07 174.73 962.05 175.12 168.47 927.84 180.25 167.24 626.63 178.81 112.05 928.14 198.10 183.87
TSTPS St-I 2145.54 207.08 444.29 2207.97 233.14 514.76 2163.00 294.27 636.51 986.91 353.29 348.67 2161.45 328.53 710.11
TSTPS St-II 1349.39 216.01 291.48 1474.44 215.44 317.65 1360.38 301.56 410.23 690.24 352.69 243.44 1359.40 328.10 446.02
FSTPS 1464.49 302.57 443.12 1550.92 352.55 546.77 1476.42 417.14 615.88 675.75 490.95 331.76 1475.36 467.33 689.47
KhTPS St-I 840.63 275.32 231.44 766.29 289.88 222.13 847.47 318.82 270.19 401.73 418.34 168.06 846.86 407.96 345.48
KhTPS St-II 60.72 279.63 16.98 173.10 323.34 55.97 209.16 345.03 72.17 72.40 441.30 31.95 209.01 413.59 86.44
Total Central Thermal 5860.77 243.54 1427.31 6172.72 268.48 1657.28 6056.42 331.05 2004.97 2827.03 397.55 1123.88 6052.08 376.32 2277.53
Total Central Sector 6784.93 236.12 1602.04 7134.77 255.89 1825.75 6984.26 311.02 2172.22 3453.66 357.86 1235.93 6980.22 352.63 2461.40
UI Over Drawal 554.32 147.33 81.67 304.81 207.01 63.10 Power Banking - -21.83 5.06 - 23.49 -
IEX & Others 1.66 PGCIL Tr. Charge 21.19 151.17 21.56 150.50
ERLDC Charges - - 0.45 3.15
TOTAL GRIDCO 21003.70 174.58 3666.85 22,868.98 197.77 4522.70 23489.18 210.32 4940.30 12022.59 206.29# 2480.18 24096.88 236.17 5691.02
6. Harnessing of power from Renewable Energy Sources:
As per the estimation of Odisha Renewable Energy Development Agency (OREDA), the Renewable
energy power potential of Odisha state is around 2500 MW (excluding solar) as presented below .
RE power potential of Odisha
Sr No Source Potential (MW) 1 Wind Energy 1700 2 Biomass Power 350 3 Micro/ Mini /Small hydro 360 4 Municipal Solid / liquid waste 20 MW 5 Solar 5.5 kWh/sqm/day
As per the Electricity Act, 2003, promotion of cogeneration and generation of electricity from
renewable sources of energy have been made the explicit responsibility of the SERCs. According to
Clause 6.4 of Tariff Policy and provisions of section 86(1)(e) of the Act, the Appropriate
Commission shall fix a minimum percentage for purchase of energy from such sources taking into
account availability of such resources in the State and its impact on retail tariffs. Such percentage for
purchase of energy should be made applicable for the tariffs to be determined by the SERCs w.e.f.
April 1, 2006. Again the National Action Plan on Climate Change (NAPCC) prepared by Prime
Minister’s Council on Climate Change under Clause 4.2.2 states that at the National level for FY
2010 target for RE Purchase may be set at 5% of total grid purchase, to be increased by 1% each
year for 10 years. SERCs may set higher target than this minimum at any point of time.
Policy for development of renewable energy sources in the State is being formulated by the State
Govt. The State Regulatory Commission has to determine the tariff for various renewable energy
technologies and promote them.
The levellized generic tariff for various renewable sources of energy having “Single part tariff’ is
approved as in the following table:
10
Particular Levellised Total Tariff (for the
control period 2010-11 to 2012-13)
(Rs./kWh)
Benefit of Accelerated
Depreciation (if availed)
(Rs./kWh)
Net Levellised Tariff (upon adjusting for
Accelerated Depreciation benefit) (if
availed) (Rs./kWh)
Tariff Period (Years)
Wind Energy 5.31 (0.83) 4.48 13 SHP projects of 5 to 25 MW capacity 3.64 (0.55) 3.09 13
SHP projects below 5 MW capacity 3.91 (0.60) 3.31 35
Solar PV 17.80 (3.03) 14.77 25 Solar Thermal 14.73 (2.41) 12.32 25
The levellized generic tariff for various renewable sources of energy having “Single part tariff with
two components “ is approved as in the following table:
Particular Levellized fixed
component of Tariff
(Rs./kWh)
Variable(Fuel )
Component of tariff for FY 2011-12
Effective tariff for
FY 2011-12
Benefit of Accelerated
depreciation (if availed)
(Rs./kWh)
Net Tariff (Rs./kWh)
Biomass 2.02 3.08 5.10 (0.21) 4.89
Non-fossil fuel based co-generation 2.26 2.24 4.50 (0.28) 4.22
OERC in its order dt 30.09.2010 vide Case No.-59/2010 has issued a Regulation fixing the RPO (Renewable Purchase Obligation) in the State of Odisha .Accordingly, the year and source wise RPO would be as below:
Year-wise
target
Minimum quantum of purchase in percentage (in terms of energy consumption in the State in KWH)
Renewable Co-generation Total Solar Non-solar
2009-10 (Actual)
- 0.80 3.45 4.25
2010-11 - 1.0 3.50 4.5 2011-12 0.10 1.20 3.70 5.0 2012-13 0.15 1.40 3.95 5.5 2013-14 0.20 1.60 4.20 6.0 2014-15 0.25 1.80 4.45 6.5 2015-16 0.30 2.00 4.70 7.0
11
7. Distribution a) OVERALL PERFORMANCE OF DISCOMS
(DISCOMs of Odisha have been privatized since 1999.)
1999-00 2008-09 2009-10
(Provisional) 2010-11
(Provisional) 2011-12
(Provisional)
Actual (Aud)
OERC Approval Actual OERC
Approval Actual OERC Approval Actual OERC
Approval
Actual upto
Sept,2011 A. DISTRIBUTION LOSS (%) CESU 44.89% 29.30% 40.34% 26.30% 39.43% 25.37% 38.30% 24.00% 38.30%
NESCO 43.35% 25.50% 34.57% 23.00% 32.52% 18.46% 32.75% 18.40% 33.29%
WESCO 44.17% 25.00% 33.55% 22.50% 34.68% 19.93% 38.05% 19.70% 38.28%
SOUTHCO 41.84% 30.40% 47.78% 27.92% 48.02% 27.82% 48.00% 26.50% 48.00%
ALL ODISHA 43.91% 27.00% 37.50% 24.45% 37.24% 22.22% 38.34% 21.71% 38.28%
B. COLLECTION EFFICIENCY (%)
CESU 69.72% 95.00% 91.80% 98.00% 97.09% 98.00% 95.60% 99.00% 94.30%
NESCO 79.37% 95.00% 92.50% 98.00% 95.24% 98.00% 94.34% 99.00% 92.84%
WESCO 83.36% 96.60% 93.86% 98.00% 98.38% 98.00% 93.38% 99.00% 89.31%
SOUTHCO 78.75% 94.00% 94.21% 98.00% 95.89% 98.00% 92.00% 99.00% 89.00%
ALL ODISHA 77.19% 95.40% 92.98% 98.00% 96.96% 98.00% 93.06% 99.00% 91.89%
C. AT & C LOSS (%)
CESU 61.58% 32.84% 45.23% 27.77% 41.19% 26.86% 41.00% 24.76% 41.80%
NESCO 55.04% 29.23% 39.48% 24.54% 35.73% 20.09% 36.56% 19.22% 38.06%
WESCO 53.46% 27.55% 37.63% 24.05% 35.74% 21.53% 42.15% 20.50% 44.87%
SOUTHCO 54.20% 34.58% 50.80% 29.36% 50.16% 29.27% 52.00% 27.23% 53.12%
ALL ODISHA 56.71% 30.36% 41.89% 25.96% 39.15% 23.77% 42.62% 22.49% 43.29%
D. REALIZATION PER UNIT INPUT (P/U)
CESU 93.00 196.28 165.73 201.72 173.98 236.73 223.08 303.03 244.67
NESCO 108.87 191.62 178.33 192.07 188.90 260.69 225.67 336.39 273.45
WESCO 130.19 211.45 201.86 203.12 200.58 257.15 218.01 328.40 256.11
SOUTHCO 116.93 157.50 141.77 169.44 138.33 196.07 165.19 259.65 185.18
ALL ODISHA 109.85 195.88 178.27 196.32 181.98 244.37 215.19 313.14 247.10
12
1999-00 2008-09 2009-10
(Provisional) 2010-11
(Provisional) 2011-12
(Provisional)
Actual (Aud)
OERC Approval Actual OERC
Approval Actual OERC Approval Actual OERC
Approval
Actual upto
Sept,2011
LT PERFORMANCE OF DISCOMs (Based on Performance Review Data)
A. L T LOSS (%)
CESU 50.48% 36.00% 52.00% 35.04% 51.97% 29.40% 50.20% 29.20% 51.60%
NESCO 62.26% 44.50% 59.40% 33.19% 55.83% 29.40% 55.36% 27.05% 55.21%
WESCO 60.64% 46.70% 65.65% 35.86% 62.49% 29.40% 63.90% 27.11% 61.96%
SOUTHCO 48.85% 33.40% 57.12% 29.50% 56.22% 29.40% 55.00% 27.75% 55.00%
ALL ODISHA 55.11% 40.30% 58.06% 34.04% 56.26% 29.40% 56.58% 27.98% 54.99%
B. COLLECTION EFFICIENCY IN LT (%)
CESU 69.72% 95.00% 84.63% 98.00% 96.51% 98.00% 87.30% 99.00% 89.80%
NESCO 79.37% 95.00% 72.61% 98.00% 77.43% 98.00% 75.60% 99.00% 72.51%
WESCO 83.36% 96.60% 73.42% 98.00% 76.01% 98.00% 73.75% 99.00% 73.83%
SOUTHCO 78.75% 94.00% 89.10% 98.00% 92.77% 98.00% 88.00% 99.00% 86.00%
ALL ODISHA 77.19% 95.40% 80.63% 98.00% 87.62% 98.00% 83.21% 99.00% 80.47%
C. AT & C LOSS FOR LT (%)
CESU 65.47% 39.20% 59.38% 36.34% 53.65% 30.81% 56.50% 29.91% 56.60%
NESCO 70.05% 47.28% 70.52% 34.53% 65.80% 30.81% 66.25% 27.78% 67.53%
WESCO 67.19% 48.51% 74.78% 37.14% 71.49% 30.81% 73.38% 27.84% 71.91%
SOUTHCO 59.72% 37.40% 61.79% 30.91% 59.39% 30.81% 61.00% 28.47% 64.00%
ALL ODISHA 65.35% 43.05% 66.18% 35.36% 61.68% 30.81% 63.87% 28.70% 63.78%
Business Plan Target for 2012-13 (Overall)
Distribution
Loss Collection Efficiency AT&C Loss
CESU 23.00% 99.00% 23.77%
NESCO 18.35% 99.00% 19.17%
WESCO 19.60% 99.00% 20.40%
SOUTHCO 25.50% 99.00% 26.25% All Odisha 21.20% 99.00% 21.99%
13
b) LT – DIVISIONAL PERFORMANCE OF DISCOMS CESU
FY 2011-12 FY 2010-11 Change in
Realization per Input-
LT 2011-12
Realizati
on per Input LT 2010-11
Percentage Improveme
nt Sl. No.
Name of Division Overall Loss (%)
Overall AT & C Loss (%)
Overall Loss (%)
Overall AT & C Loss (%)
AT & C Loss
OERC TARGET 29.90% 24.80% 30.81% 26.90% -2.10% 220 170.87 28.75% 1 BCDD-1 8.90% 12.30% 9.30% 14.40% -2.10% 382 359.92 6.13% 2 BCDD-2 30.10% 25.10% 25.50% 23.00% 2.10% 260 260.72 -0.28% 3 BED-Bhu 27.30% 27.10% 28.60% 29.10% -2.00% 278 260.7 6.64% 4 NEDN-Nimapada 72.40% 73.50% 71.90% 73.20% 0.30% 79 79.26 -0.33% 5 PED-Puri 64.50% 64.30% 65.20% 65.50% -1.20% 122 116.39 4.82% 6 NED-Nayagada 53.80% 57.00% 53.60% 50.70% 6.30% 128 133.1 -3.83% 7 KED-Khorda 61.10% 42.90% 60.20% 44.50% -1.60% 129 125.45 2.83% 8 BED-Balugaon 61.30% 49.70% 60.40% 50.30% -0.60% 112 112.57 -0.51% 9 CED 73.30% 53.70% 72.70% 56.90% -3.20% 86 83.94 2.45% 10 CDD-I 33.90% 35.40% 36.90% 39.00% -3.60% 258 233.79 10.36% 11 CDD-II 46.80% 34.80% 41.90% 33.80% 1.00% 204 213.27 -4.35% 12 AED-Athagada 77.40% 34.60% 75.40% 36.30% -1.70% 65 68.88 -5.63% 13 SED 69.40% 71.90% 67.50% 70.20% 1.70% 85 91.13 -6.73% 14 KED-I 62.80% 65.20% 58.30% 61.50% 3.70% 113 120.37 -6.12% 15 KED-II 68.50% 70.30% 67.80% 69.70% 0.60% 90 91.19 -1.30% 16 PDP-Paradeep 67.70% 25.60% 65.20% 28.30% -2.70% 100 106.12 -5.77% 17 JED 70.10% 72.50% 70.10% 72.50% 0.00% 89 85.58 4.00% 18 DED 75.20% 55.90% 74.20% 55.10% 0.80% 80 79.61 0.49% 19 ANED-Anugul 68.30% 60.70% 71.60% 58.20% 2.50% 114 98.33 15.94% 20 TED-Chainpal 74.20% 25.20% 75.50% 16.80% 8.40% 83 75.65 9.72% CESU Total 56.50% 41.80% 56.60% 41.00% 0.80% 150 143.88 4.25%
NESCO
For FY 2011-12 For FY 2010-11 LT Realization to LT Input P/U
Percentage Change
Sl. No.
Name of Division AT & C Loss (%) AT & C Loss (%) Change in AT&C
Loss
LT TOTAL LT TOTAL for
2011-12 for
2010-11 OERC TARGET 27.78% 19.22% 30.81% 20.09% -0.87% 227.45 143.20 58.83%
1 BED, Balasore 41.38% 30.53% 35.98% 26.79% 3.74% 217 220 -1.36% 2 BTED, Basta 71.82% 73.55% 65.18% 67.58% 5.97% 72 81 -11.11% 3 JED, Jaleswar 67.38% 52.70% 61.49% 49.58% 3.12% 84 84 0.00% 4 CED, Balasore 73.05% 24.69% 66.20% 18.89% 5.80% 82 96 -14.58% 5 BNED, Bhadrak (N) 71.11% 35.49% 70.77% 32.11% 3.38% 94 91 3.30%
6 BSED, Bhadrak (S) 81.59% 78.96% 78.67% 78.85% 0.11% 49 56 -12.50% 7 SED, Soro 61.36% 63.20% 67.03% 68.45% -5.19% 109 93 17.20%
8 BPED, Baripada 61.59% 60.72% 63.42% 62.08% -1.36% 127 114 11.40% 9 UED, Udala 71.54% 73.48% 72.07% 73.90% -0.42% 91 81 12.35%
10 RED, Rairangpur 69.87% 67.77% 69.77% 66.86% 0.91% 101 93 8.60%
14
For FY 2011-12
For FY 2010-11 Change
in AT&C Loss LT Realization to
LT Input P/U
Percentage Change
Sl. No.
Name of Division AT & C Loss (%)
Percentage Change
LT TOTAL LT TOTA
L for
2011-12 for
2010-11
11 JRED, Jajpur Road 72.90% 18.57% 71.92% 19.22% -0.65% 92 87 5.75%
12 JTED, Jajpur Town 66.93% 69.58% 66.46% 69.14% 0.44% 88 82 7.32%
13 KUED, Kuakhia 66.60% 63.74% 62.70% 65.68% -1.94% 102 103 -0.97% 14 KED, Keonjhar 69.58% 47.76% 55.60% 18.09% 29.67% 112 147 -23.81%
15 AED, Anandapur 79.41% 73.40% 80.58% 73.94% -0.54% 62 58 6.90% 16 JOED, Joda 59.44% 14.93% 147
NESCO Total 67.53% 38.06% 65.74% 36.04% 2.02% 103 101 1.98% WESCO
FY 2011-12 FY 2010-11 Change in AT & C Loss
Realization Per Unit-LT FOR 2011-12 (Paise)
Realization Per Unit-LT FOR 2010-11 (Paise)
Percentage Change
Sl. No.
NAME OF DIVISION
AT & C LOSS (%)
AT & C LOSS (%)
LT Overall LT Overall OERC TARGET 27.84% 20.50% 30.81% 21.53% -1.03% 198.1 112.07 76.76%
1 BARGARH(W) 82.41% 81.24% 84.33% 82.70% -1.46% 46.2 39.44 17.14%
2 NUAPADA 80.00% 80.14% 81.84% 81.17% -1.03% 63.65 52.13 22.10%
3 SONEPUR 80.81% 77.16% 79.46% 77.05% 0.11% 48.7 48.92 -0.45%
4 BARGARH 75.75% 71.22% 79.11% 67.75% 3.47% 71.63 57.75 24.03%
5 BOLANGIR 77.80% 75.31% 78.51% 75.25% 0.06% 67.3 62.38 7.89%
6 SUNDERGARH 75.71% 59.05% 75.28% 59.75% -0.70% 72 68.69 4.82%
7 SAMBALPUR 71.90% 57.57% 74.34% 60.05% -2.48% 99.24 82.35 20.51%
8 TITLAGARH 75.14% 67.70% 73.27% 63.80% 3.90% 75.18 73.89 1.75%
9 KWED 70.39% 72.87% 72.65% 74.76% -1.89% 88.62 77.8 13.91%
10 DEOGARH 69.64% 57.32% 69.69% 50.34% 6.98% 85.15 83.36 2.15%
11 JHARSUGUDA 68.77% 27.34% 69.52% 22.88% 4.46% 103 91.87 12.11%
12 SAMBALPUR(E) 70.05% 58.26% 69.50% 57.34% 0.92% 102.21 97.43 4.91%
13 KEED 66.02% 63.37% 66.61% 62.58% 0.79% 105.27 100.63 4.61%
14 ROURKELA 63.76% 36.56% 64.87% 37.78% -1.22% 121.91 109.63 11.20%
15 RAJGANGPUR 50.42% 14.72% 60.53% 12.45% 2.27% 187.89 132.37 41.94%
16 ROURKELA SADAR 64.25% 41.32%
127.14
Total WESCO 71.91% 44.87% 73.38% 42.15% 2.72% 89.47 78.71 13.67%
15
SOUTHCO
FY-2011-12 FY 2010-11
Change in AT & C Loss
LT Realization to LT Input P/U for 2011-12
LT Realization to LT Input P/U for 2010-11
Percentage Change
Sl. No. Name of Division
AT & C LOSS (%)
AT & C LOSS (%)
LT TOTAL LT Over All
OERC TARGET 28.47% 27.20% 30.81% 29.27% -2.07% 203.00 143.70 41.27% 1 ASKA- II 82.00% 83.00% 76.63% 78.10% 4.90% 53.00 64.01 -17.20% 2 ASKA- I 72.00% 72.00% 75.43% 75.91% -3.91% 86.00 67.69 27.06% 3 BHANJANAGAR 73.00% 74.00% 73.13% 74.96% -0.96% 82.00 74.49 10.09%
4 MALKANGIRI 78.00% 65.00% 71.93% 66.21% -1.21% 70.00 89.79 -22.04% 5 PURUSOTTAMPUR 74.00% 74.00% 67.98% 68.89% 5.11% 75.00 86.37 -13.17% 6 BOUDH 74.00% 70.00% 67.15% 65.54% 4.46% 81.00 96.50 -16.06% 7 CHATRAPUR 74.00% 39.00% 66.61% 37.93% 1.07% 78.00 93.16 -16.27%
8 DIGAPAHANDI 69.00% 71.00% 66.23% 68.61% 2.39% 87.00 91.82 -5.25% 9 PARALAKHEMUNDI 61.00% 62.00% 59.98% 62.35% -0.35% 119.00 117.83 0.99%
10 KORAPUT 69.00% 33.00% 59.23% 29.18% 3.82% 103.00 131.74 -21.81%
11 NOWRANGPUR 70.00% 64.00% 58.88% 53.10% 10.90% 106.00 141.09 -24.87% 12 JEYPORE 56.00% 36.00% 56.82% 32.41% 3.59% 157.00 145.07 8.22%
13 PHULBANI 61.00% 64.00% 56.55% 59.11% 4.89% 125.00 135.70 -7.89% 14 GUNUPUR 51.00% 53.00% 54.65% 56.65% -3.65% 154.00 136.55 12.78%
15 BERHAMPUR- I 47.00% 39.00% 45.83% 41.03% -2.03% 191.00 174.75 9.30% 16 BERHAMPUR- II 40.00% 44.00% 41.40% 44.40% -0.40% 212.00 186.91 13.43% 17 RAYAGADA 39.00% 28.00% 40.15% 31.08% -3.08% 208.00 190.03 9.46%
18 BERHAMPUR- III 53.00% 51.00% 33.08% 35.10% 15.90% 153.00 203.19 -24.70% TOTAL SOUTHCO 64.00% 53.00% 60.87% 52.04% 0.96% 116.00 118.90 -2.44%
16
c) Direction of the Commission to the Discoms on the Performance Review for 2011-12 (upto Sept. 2011)
1. As per Clause 7.1 of the License Conditions the licensee is required to develop and maintain
an efficient, coordinated and economical distribution system in the Area of Distribution and
effect supply of electricity to consumers in such area of supply in accordance with the
provisions of the Act, the State Act, Rules, Regulations, Orders and Directions of the
Commission. Basically the Licensee is the utility service oriented company and servicing
consumers in proper manner is the primary responsibility of the Licensee.
In this connection it must be made clear to all employees of the distribution company that
collection of legitimate revenue from the consumers is one of the essential requirements for
maintaining the quality service to the consumers, because without collection of revenue it
shall not be possible to pay the power purchase cost, meet the expenditure on salary,
operation and maintenance expenditure and other essential requirement to maintain the
standard of service to the consumers. Hence, each and every employee starting from the
Managing Director down below upto the Lineman is individually, jointly and severally
responsible to ensure proper service to the consumers by discharging their duties which inter
alia includes collection of revenue as one of the most important functions. This must be made
clear to all employees of the concerned distribution companies.
2. Some employee organization of the distribution companies have demanded that Managing
Director/CEO should not review the performance of JEs directly when SE, EE and SDO are
there. It has been reported that some JEs have also boycotted the review meeting taken by
MD, WESCO. This type of attitude and stand of the employees is simply reprehensive and
totally uncalled for. In the hierarchical structure of administration of the distribution licensee,
all employees down below the MD/CEO heading the organization are accountable to him/her
(MD/CEO) for their performance in all respects, including proper maintenance of distribution
network and collection of revenue. Hence, MD/CEO can and shall review the performance of
all employees starting from SEs, EEs, Assistant Engineers, Junior Engineers and even
lineman at any time. The boycotting of any performance review meeting taken by MD/CEO
by any employees amounts to dereliction of duties and calls for stringent disciplinary action
against such employees/group of employees. This must be abundantly made clear to all
employees of the distribution companies.
17
Any employee indulging in anti-consumer activities or showing non-cooperation in
collection of revenue must be sternly dealt with and the Commission shall not tolerate any
leniency in this respect.
3. Unless the overall AT&C loss is reduced substantially and per unit input realization is
improved, it would be difficult for the DISCOMs to meet the power purchase cost and other
day to day expenses like salary, O&M expenses etc. in view of rising procurement cost of
power. The worst division should be identified and the concerned Executive Engineer may be
asked to reduce at least 30% of the present level of loss by 31.3.2012. The salary of the
Executive Engineer and the other staffs upto lineman for the month of March, 2012 shall not
be paid unless the minimum target of 30% of the present level of loss is reduced by
31.3.2012. Similarly, all other divisions should be asked to reduce the present level of loss at
least by 20% by end of 31.3.2012, failing which appropriate action should be taken against
the Executive Engineer and the staff below him upto the lineman.
4. The other important directions issued by the Commission as indicated below vide their letter
No. Dir(T)-336/08/2544 dated 13.1.2012 shall be scrupulously followed and compliance
reported as per the time schedule indicated therein:-
(1) Feeder-wise responsibility should be fixed on the concerned JE and he/she should be
designated as Feeder Manager. The Feeder Manager shall be personally responsible
for reduction of loss in the feeder in his charge.
(2) Routine maintenance like trimming of trees, cleaning and ensuring neutral grounding
of transformer, replacement of broken wires and loose connection would reduce the
loss to a substantial extent as confirmed by Chairman-cum-CEO, CESU during
performance review on 27.12.2011.
(3) In the past instruction was issued to cross check the meter reading taken by the meter
readers or the employees of the agency engaged for meter reading and billing. In a
large number of cases in CESU under billing has been detected. There should be
regular cross checking of meter readings and the result thereof should be reported to
the Commission before 15th of every month.
(4) It is seen that the meter readers are also not covering all the consumers who have
been even brought to the billing fold. Monthly review should be conducted by the
concerned CEO/MD to see that all the consumers in the billing fold are covered under
the billing cycle.
18
(5) From the review, it is seen that bills raised during the current financial year have not
been collected fully and arrear has been added which works out to Rs.294.90 crore for
the period 01.04.2011 to 30.09.2011 as indicated below:
Name of DISCOMs NESCO WESCO SOUTHCO CESU Total
Addition of arrear
(Rs. in Crore)
54.43 96.71 31.21 112.55 294.90
Special drive should be launched for collection of arrear both in respect of Govt.
departments, urban local bodies, lift irrigation points, pani panchayat, urban water
supply, rural water supply, hospital, etc. as well as other private consumers including
HT & EHT consumers. All DISCOMs must ensure that all EHT and HT consumers
not only pay the current monthly bills in time but also all arrears outstanding against
them shall have to be cleared by 31.03.2012 at the latest. The DISCOMs are directed
to report the monthly progress by 15th of the succeeding month.
(6) Adequate number of call centers should be opened for facility of registering
complaint as well as collection and giving new connection to the consumers and
taking up other activities to provide better service to the consumers.
(7) In the rural areas more Women Self Help Groups should be entrusted with billing,
collection and constant liaison should be held with the District Administration to
entrust number of villages to Women Self Help Groups. Each DISCOMs must cover
at least 30000 consumers through Women Self Help Groups during 2011-12.
(8) As decided in the meeting held on 29.01.2011, the agencies, organizations willing to
supply install smart meters which can connect/dis-connect, enhance load remotely,
and facilitate meter reading along with other standard meter features should be
entrusted with supply, installation, billing and collection and increase in the revenue
per input should be appropriately shared keeping in view their requirement to recover
the cost of capital. Preferably one or more division should be entrusted to such of the
willing agencies on Build-Own-Operate-Transfer (BOOT) modality with revenue
sharing basis so that they will have economy of scale to ensure economy in operation
and better performance. The broad scope of the work may be as per Annexure
attached herewith subject to detail negotiation and agreement between licensees and
agencies. The firms, who have participated in the presentation at OERC on the
subject be approached for detailed meeting and negotiation at your end. After
19
negotiation and formal agreement vetting of the Commission may be sought for
before signing the final agreement.
(9) Apart from the above, the Commission vide letter No.2527 dtd.11.01.2012 has also
directed as under:
“Pending Introduction of Smart Grid Solutions deploying BOOT Model on Revenue
sharing basis as stated above, I am directed to inform that the Commission desires
that all consumers with a Contract Demand of 20 KW or more of your DISCOM
should be covered under AMR (who are not covered under BOOT Model)
undertaking a Special Programme through retrofitting wherever required within 3
months time i.e. by 15.04.2012 positively, if required, meeting such expenditure from
Capex Funding. The arrangement for monitoring of such AMRs in CEO’s Office,
Division Office as well as in OERC shall also be made installing suitable terminals at
such places so as to keep a strict vigil on the performance of AMRs and on billing of
high value consumers. The road map of the completion of 100% AMR for high value
consumers may please be furnished for information of the Commission.”
5. All licensees are directed to ensure strict compliance of the various directions of the
Commission as per the time schedule indicated above and fix responsibilities and
accountability at different levels to improve the overall performance failing which stringent
action should be taken against the defaulting and non-performing officers and staffs.
8. Why rise in tariff is inevitable?
The average tariff for the distribution companies consists of 74.70% towards power purchase cost,
6.9% towards transmission & SLDC charges and 18.30% towards distribution cost. If there is
increase in the cost of generation and consequently the power purchase cost of GRIDCO, the retail
tariff is bound to increase.
Increasing cost of purchase of power by GRIDCO After 1999-2000 it is invariably seen that GRIDCO has been purchasing power from different
sources at an average cost which is higher than the rate approved by the Commission. As a
result, additional burden is being borne by GRIDCO in order to meet the requirement of the
consumers of the State. The Table below gives a comparative picture of quantum energy, the
rate and total power purchase cost approved by the Commission against which the actual
quantum of energy purchased, the average rate and the total power purchase costs which are
substantially higher.
20
Table-1
Comparison of Power Purchase Cost of Gridco Approved by the Commission in the
ARR vrs. Actual
YEAR COMMISSION's APPROVAL ACTUAL
Energy MU Rate P/U Total cost
Rs.in Cr. Energy MU Rate P/U
Total cost Rs.in Cr.
1999-00 10,176.13 103.36 1,051.82 11,197.38 104.10 1,165.60 2000-01 11,011.39 105.76 1,164.56 12,400.01 112.88 1,399.72 2001-02 12,345.07 94.60 1,167.82 12,467.03 95.27 1,187.77 2002-03 13,312.22 106.71 1,420.60 12,025.61 133.38 1,603.97 2003-04 14,818.80 115.52 1,711.87 15,896.76 100.33 1,594.89 2004-05 17,395.16 103.67 1,803.29 17,742.93 97.46 1,729.31 2005-06 16,640.02 110.36 1,836.38 16,806.08 120.41 2,023.58 2006-07 15,414.79 113.97 1,756.84 18,866.10 117.22 2,211.55 2007-08 17,539.47 119.91 2,103.11 20,934.39 119.91 2,510.28 2008-09 18,460.26 127.40 2,351.75 20,049.27 149.61 2,999.64 2009-10 19,719.37 148.27 2,923.80 20,956.19 196.94 4,127.03 2010-11 21,003.75 174.58 3,666.85 22,868.98 197.77 4,522.70
2011-12 23,489.18 210.32 4,940.30 17,575.26
(Upto Dec 2011) 210.00 3,690.81
2012-13 24,096.88 236.17 5,691.02
Going by the past experience and in view of the rising cost of coal and furnace oil not only
consumption of energy would increase but the rate of purchase price may also rise
substantially which is corroborated from the facts and figures of 2010-11 and also from the
previous years (refer to Table above). This is again substantiated by rising sale price of ‘F’
grade and ‘G’ grade coal used in the thermal power stations by 19% and 23% respectively
(average 21%) announced by Mahanadi Coalfield Ltd., a subsidiary of Coal India. Added to
this, MCL has started billing of excise duty of 5% from 1.3.2011. Thus with hike in price of coal
together with levy of excise duty the coal price is going to increase by 29% which was not fully
factored in the tariff hike approved by the Commission from 01.4.2011. Consequently, the
GRIDCO’s power purchase cost from NTPC and other thermal power stations is going to
increase from Rs.3.50 to Rs.4.00 per unit. For the end consumers the hike could possibly in
the range of 70-75 paise per unit keeping in view the distribution loss. In case of OPGC the on
account of enhanced excise duty the additional burden would be Rs.7.50 crore per annum
which would hike up the power purchase cost of GRIDCO.
It may be appreciated that GRIDCO was purchasing power at a higher price but selling at a
lower price to the distribution companies to keep the Retail Tariff at reasonable level in order
to safeguard the interest of the consumers. Even though GRIDCO is purchasing power from
21
different sources at a higher cost this is not being fully factored into the retail tariff for recovery
from the consumers and the BST price which forms a major component of retail tariff has
been kept in some years at a level lower than the purchase price. The gap left in the ARR of
GRIDCO was supposed to be filled up through profit earned from sale of surplus power but
with the rise in demand of the existing consumers as well as increase in number of consumers
the surplus power is not available. Still then the Commission has left gap in the account of
GRIDCO to keep the BST price at a low level in order to keep the retail tariff affordable. This
would be evident from the table given below:-
ARR GAP OF GRIDCO (Rs. in crore)
With rise in demand and consequently non-availability of surplus power for trading to earn
profit, it is no longer possible to keep the BST at a lower level to ensure low retail tariff for the
consumers. In fact, the low BST for 2008-09, 2009-10 and 2010-11has resulted in increased
gap in the account of GRIDCO and the cumulative gap at the end of 2010-11 has reached
2266.60 crore. Even with the average BSP of 231.65 paise per unit for 2011-12 and if there is
no further increase in cost of purchase of power by GRIDCO approved at 210.32 paise per
unit the gap for the year has been estimated at Rs.746.05 crore and the cumulative gap upto
31.3.2012 may go up to –(-) 3283.84 crore. The table given below explained how the gap is
going up from year to year.
Financial Year
Gap in ARR
(Approved)
Actual Gap Net Gap
Rate approved for
power purchase by
GRIDCO(P/U)
BST Rate approved for sale to DISCOMs
(P/U) 2006-07 (-) 504.52 547.55 43.03 113.97 120.85 2007-08 (-) 464.86 1052.34 587.48 119.91 121.59 2008-09 (-)410.05 528.62 118.57 127.40 122.15 2009-10 (-)882.85 (-)657.84 (-)1540.69 148.27 122.20 2010-11 (-)806.15 (+)238.44 (-)567.71 174.58 170.25
2011-12 (-)746.05 (-) 1017.24 (estimated by
GRIDCO)
(-) 1017.24 210.32 231.65
2012-13 (-)700.58 236.17 270.74
22
Truing up of GRIDCO for 2010-11 (Provisional) (Rs. in Crore)
Financial Year
Gap in revenue requirement compared to the approved amount
Gap in revenue from sale of power compared to the approved amount
Total gap (for the year)
Add: approved gap in ARR allowed by the Commission
Gap considered for true up
Cumulative Gap (+/-)
(1) (2) (3) 4 (2+3) 5 6 (4+5) 7
1996-97 -295.00
1997-98 -310.15 5.86 -304.29 0.68 -303.61 -598.61
1998-99 -236.10 -420.39 -656.49 0.19 -656.30 -1254.91
1999-00 -230.33 244.14 13.81 -30.91 -17.10 -1272.01
2000-01 -359.42 194.43 -164.99 0.00 -561.97 -1437.00
2001-02 13.74 65.61 79.35 43.59 122.94 -1314.06
2002-03 -297.86 -264.11 -561.97 0.00 -561.97 -1876.03
2003-04 -79.79 586.13 506.34 0.00 506.34 -1369.69
2004-05 -73.19 322.13 248.94 217.35 466.29 -903.40
2005-06 -403.92 384.32 -19.60 15.72 -3.88 -907.28
2006-07 -175.47 723.02 547.55 -504.52 43.03 -864.25
2007-08 149.93 902.41 1052.34 -464.86 587.48 -276.77
2008-09 -410.14 938.76 528.62 -410.05 118.57 -158.20
2009-10 -1006.67 348.83 -657.84 -882.85 -1540.69 -1698.89
2010-11 (-) 589.29 827.73 238.44 (-) 806.15 (-) 567.71 (-) 2266.60
2011-12 (Prov.) -746.05 (-) 1017.24
(estd. by GRIDCO) (-) 3283.84
2012-13 -700.58
23
9. Salient Features of Tariff for FY 2012-13
The Commission had to do a tight rope walk in approving tariff for FY 2012-13 as it had to safeguard the consumers from a tariff shock arising out of the increase in generation cost and power purchase cost, provide the utilities with reasonable revenue to run their business and keep the cross-subsidy within the stipulated limits. The highlight of the tariff for FY 2012-13 is given below.
9.2 Highlights of Tariff:- No rise in tariff for irrigation, pumping and agriculture and allied agricultural activities, from
the present level of 110 paise and 120 paise respectively for the consumers availing such power supply in LT. Marginal rise from 320 paise to 380 paise for allied agro industrial activities.
Similarly no rise for irrigation, pumping & agriculture and allied agricultural activities, from the present level of 100 paise and 110 paise respectively for the consumers availing such power supply in HT. Marginal rise from 310 paise to 370 paise in case allied agro industrial activities.
Reduction of tariff from 420 paise to 400 paise for the consumers Bulk Domestic availing power supply at HT voltage.
Ice factories depending upon marine fishing has to pay their electricity bill on the maximum demand achieved instead of contract demand during the banned period imposed by Fishery Department of GoO.
Relaxation of 50 paise per unit for the EHT and HT industrial consumers committed in writing to pay energy bills at 70% load factor irrespective of their consumption below 70% load factor.
Any LT consumer who wants to avail quality power by installing own transformers either in single phase or in three phase and pay the monthly bills regularly within the rebate time shall get additional rebate/concession of 5% of energy charges in addition to normal rebate. If energy bills are not paid within the rebate period no rebate shall be allowed.
While approving the average cost of supply as Rs.460.51 for the FY 2012-13, the Commission has fixed 220 paise upto 50 units, 390 pasie for the consumption above 50 units & upto 200 units, 490 paise for the consumption above 200 units & upto 400 units and 530 paise for the consumption above 400 units for the domestic category. The tariff approved by the Commission for the above slab in domestic category during FY 2011-12 was 140 paise (upto 50 units), 350 paise (above 50 units less than 200 units), 430 paise (above 200 units less upto 400 units) and 480 paise (above 400 units)
Average tariff for consumption of 50 units, 100 units, 200 units, 300 units, 400 units, 500 units and 600 units is Rs.2.20 kwh, Rs.3.05 kwh, Rs.3.48 kwh, Rs.3.95 kwh, Rs.4.19 kwh and Rs.4.41 kwh and Rs.4.56 respectively, which is around 52%, 34%,25%, 14%, 9%, 4%
24
and 1.02% less than average cost of supply of Rs.4.61 approved by the Commission. A consumer is required to pay an average tariff of Rs.4.66 for the consumption of 700 units which is 1.29% higher than the average cost of supply.
Table-1
Consumption (units)/ Month
Rate per unit in Paise
Consumptio
n(units)/ Month
Rate per unit in Paise
Consumption
(units)/ Month
Rate per unit in Paise
50 <=100 140 70.0 1.40 <=50 140.00 70.0 1.40 <=50 220.00 110.0 2.20 0.80 4.61 -52.2%
100 >100,<=200 310 140.0 1.40 >50,<=200 350.00 245.0 2.45 >50,<=200 390.00 305.0 3.05 0.60 4.61 -33.8%
200 >200 410 450.0 2.25 >200 430.00 595.0 2.98 >200 490.00 695.0 3.48 0.50 4.61 -24.5%
300 >400 410 860.0 2.87 >400 480.00 1,025.0 3.42 >400 530.00 1,185.0 3.95 0.53 4.61 -14.2%
400 1,270.0 3.18 1,455.0 3.64 1,675.0 4.19 0.55 4.61 -9.1%
500 1,680.0 3.36 1,935.0 3.87 2,205.0 4.41 0.54 4.61 -4.2%
600 2,090.0 3.48 2,415.0 4.03 2,735.0 4.56 0.53 4.61 -1.0%
700 2,500.0 3.57 2,895.0 4.14 3,265.0 4.66 0.53 4.61 1.3%
Consumption in Units
2010-11 2011-12
Tariif Schedule Total Billed
Amount (Rs)
Avg. rate per unit in Rs.
Tariif Schedule Total Billed
Amount (Rs)
Avg. rate per unit in
Rs.
Tariif Schedule
2012-13
Increase over
2011-12
Avg. cost per unit for
all Consumers
(Rs)
Comparison of tariff with Avg. Cost of Supply (%)
Total Billed
Amount (Rs)
Avg. rate per unit in
Rs.
Industries having captive generating plants, availing power in EHT or HT shall have to pay 690 paise and 708 paise respectively instead of 640 paise and 650 paise fixed during 2011-12.
Taking into all categories of consumers, there is a average tariff rise from 404.01 paise in 2011-12 to 451.84 paise in 2012-13, shows in average tariff rise of 47.83 paise from last year. (Increase in 11.8%)
Average tariff rise from Rs.506.98 paise to Rs.551.04 (44.06 paise increase) in case of EHT consumers, Rs.524.92 paise to Rs.552.09 paise (27.17 paise increase) in case of HT consumers and Rs.300.34 paise to 368.52 paise (68.18 paise increase) in case of LT consumers.
Average cost of supply has been approved as 460.51 paise during FY 2012-13 in place of 408.87 paise during FY 2011-12, thus there is an increase of 12.63%. Considering the receivables from different sources. Overall average tariff of 451.84 has been approved during FY 2012-13 as against 404.01 during FY 2011-12. Average tariff rise of 47.83 paise (11.84%) compared to last year.
Table-2 SL. NO
IN PAISE IN PERCENTAGE
1 Average Cost of Supply 327.37 408.87 460.51 51.64 12.63Overall average tariff (paise per unit) 320.58 404.01 451.84 47.83 11.84
2 Break up a. Power Purchase from generators by GRIDCO 174.58 210.32 236.17 25.85 12.29b. Debt servicing and other expenditure of GRIDCO (-) 4.33 21.33 34.57 13.24 62.07c. Total Bulk supply price of GRIDCO (a+b) payable by
DISCOM170.25 231.65 270.74 39.09 16.87
d. Tranmission Charges 23.5 25.00 25.00 0 0e. SLDC charges 0.18 0.18 0.18 0f. Distribution cost borne by the distribution companies 126.65 147.18 155.92 8.74 5.94
INCREASE BREAK UP OF THE AVERAGE TARIFF FOR 2011-12 AND 2012-13(PAISE PER UNIT)
2011-12 2012-132010-11
25
9.3 Cross Subsidy:-
Section 61(g) Electricity Act, 2003 read with para 8.3.2 of Tariff Policy, 2006 stipulates that the tariff should be within ±20% of the average cost of supply. It is worthwhile to mention here that the Hon’ble Appellate Tribunal of Electricity, New Delhi has set aside the ARR & tariff orders of DISCOMs for the FY 2010-11 and 2011-12 mainly because the cross subsidy was not within ± 20% of the cost of supply. As such, the tariff order for FY 2012-13 has been approved in consonance with the statutory provisions as mentioned above and by taking into account observations of Hon’ble ATE. As the average cost of supply is 460.51 paise for FY 2012-13, average tariff of any consumer should not be more than 552.61 paise and less than 368.41 paise. With this mandate, the Commission has fixed 368.52 paise in case of LT (-19.98% of average cost of supply), 552.09 paise for HT (+19.89% of average cost of supply) and 551.04 paise for EHT (+19.66% of average cost of supply). The following Table compares the cross-subsidy for the last three years.
Table-3 C ross-su bsid y 2012-13
Yea r L eve l o f Vo ltage
A verag e co st o f supp ly for the S ta te as a w ho le (P /U )
A verag e T a rif f P /U
C ro ss-Subs idy in
P /U
Pe rc entage o f C ross-subsid y a bove/b elow or cos t o f supp ly
1 2 3 4 5= (4) – (3 ) 6= (5 / 3 ) EH T 416.6 1 89 .24 27 .26% H T 423.5 9 96 .22 29 .39% L T 219.2 1 -108.1 6 -33.0 4%
EH T 506.9 8 98 .11 24 .00% H T 524.9 2 116 .05 28 .38% L T 300.3 4 -108.5 3 -26.5 4%
EH T 551.0 4 90 .53 19 .66% H T 552.0 9 91 .58 19 .89% L T 368.5 2 -91.99 -19.9 8%
201 0-11 32 7.37
20 12-1 3 46 0.51
201 1-12 40 8.87
9.4 Reasons for Tariff Rise
(a) Significant Rise in Generation Cost and Power Purchase Cost:-
Less low cost hydro Power:- The principal reason for tariff hike in 2012-13 is the increase in number of electricity consumers, inadequate generation of low cost hydro power to meet growing demands & rise in cost of coal and furnace oil, which ultimately lead to increased generation cost. Earlier, during 2004-05 nearly 57% of power requirement of the state was being met from low cost state own hydro power stations. It has gone down to 27% during the FY 2012-13.
Table-4
Declination of Hydro generation in over all Power Pool
FY 2004-05 FY 2008-09 FY 2009-10 FY 2010-11 (Provisional)
FY 2011-12 (Provisional upto 2/2012)
FY 12-13 (Approved)
State Demand (in MU) 12,499.45 18,771.82 19,524.80 21,244.79 19,395.00 23,085.00 State Hydro Generation for Sale
(incl. small Hydro) (in MU) 7,087.82 5,835.72 4,211.75 5,124.46 5,114.61 6,181.74
% of state hydro to total statedemand 56.7% 31.1% 21.6% 24.1% 26.4% 26.8%
26
Rise in Coal Price:- Due to rise in cost of coal and furnace oil, the Central Thermal Generating Stations have increased their cost of sale of power to GRIDCO. There has also been 30% increase in energy charge of thermal generations due to excessive rise in cost of coal, e-auction of coal, collection of 5% excise duty on imported coal and calculation of coal value on Cross Calorific Value other than Useful Heat Value. Comparative position of power purchase rate approved vis-a-vis actual energy in MU, rate per unit and cost in Rs. Crores is shown below along with the table on the price rise of coal in case of Central Thermal Generators.
Table-5
COMPARATIVE POSITION OF POWER PURCHASE RATE APPROVED VIS-À-VIS THE ACTUAL ENERGY IN MU, RATE IN PAISE PER UNIT AND COST OF RS. CRORE
Sources of Generation
Central Thermal
Commission Approval Actual FY 2009-10
Energy 5905.22 5819.62 Total Rate 197.31 221.58 Total Cost 1165.18 1289.51
FY 2010-11 Energy 5860.77 6172.72 Total Rate 243.54 268.48 Total Cost 1427.31 1657.28
FY 2011-12 Energy 6056.42 3453.66 Total Rate 331.05 357.86 Total Cost 2004.97 1235.93
FY 2012-13 Energy 6052.08 Total Rate 376.32 Total Cost 2277.53
Table-6 Price of Coal & GCV value of CGSs
FSTPS KSTPS-I KSTPS-II TSTPS-I TSTPS-
II
MONTH Price of
Coal Rs/MT
GCV of Coal
KCAL/ Kg
ECR P/U
Price of Coal
Rs/MT
GCV of Coal
KCAL/ Kg
ECR P/U
ECR P/U
Price of Coal
Rs/ MT
GCV of Coal
KCAL/ Kg
ECR P/U
ECR P/U
Apr-11 4,604.98 3,943.0 306.64 2,602.96 2,782.0 256.00 241.68 2,033.30 3,199.2 164.19 164.19 May-11 5,007.44 3,606.0 364.60 2,407.54 2,801.0 235.20 222.00 2,257.65 3,046.5 191.40 191.40 Jun-11 5,422.42 3,697.0 385.10 2,956.87 2,625.0 308.20 290.95 2,661.05 2,980.7 230.60 230.60 Jul-11 5,126.72 3,606.0 373.28 2,768.62 2,638.0 287.19 271.10 3,089.99 3,054.9 261.30 261.30 Aug-11 5,163.89 3,460.0 391.85 3,224.31 2,885.0 305.80 288.60 3,165.22 2,964.4 275.80 275.80 Sep-11 5,226.87 3,490.0 393.20 3,737.38 2,980.0 343.20 323.90 3,023.10 3,127.1 249.75 249.75 Oct-11 4,309.53 3,591.0 315.10 3,477.11 3,050.0 311.95 294.47 3,134.59 2,963.4 273.27 273.27 Nov-11 3,865.72 3,338.0 304.07 2,428.61 2,777.0 239.31 225.89 2,331.97 2,943.6 204.66 204.66 Dec-11 3,402.86 3,332.0 268.10 2,178.60 2,651.0 224.90 212.30 1,902.70 2,906.2 169.10 169.10 Jan-12 3,993.88 3,359.0 312.20 2,566.40 2,742.0 256.10 241.80 1,781.40 3,020.5 152.40 152.40
Avg. from 4/11 to 01/12
4,612.43 3,542.2 341.40 2,834.83 2,793.1 276.80 261.30 2,538.10 3,020.7 217.20 217.20
GCV = Gross Calorific Value CGSs = Central Generating Stations ECR = Energy Charge Rate
27
Actual for 2011-12
(Avg upto 1/12)
GRIDCO Proposal for 2012-
13
VC P/U FPA P/U ECR P/U VC P/U FPA P/U ECR P/U VC P/U
Escalating 20% over
actual Jan,2011
ECR P/U ECR P/U ECR P/U
TSTPS-I 41.10 71.88 112.98 41.10 129.70 170.80 41.10 155.65 196.75 217.25 292.0 34.41% 238.97
TSTPS-II 58.73 52.59 111.32 58.73 112.08 170.81 58.73 134.50 193.23 217.25 291.0 33.95% 238.97
FSTPS 98.57 121.95 220.52 98.57 195.28 293.85 98.57 234.34 332.91 341.41 480.0 40.59% 375.56
KHSTPS-I 108.50 76.42 184.92 108.50 98.56 207.06 108.50 118.27 226.77 276.79 378.0 36.57% 304.46
KHSTPS-II 125.37 51.96 177.33 125.37 74.58 199.95 125.37 89.49 214.86 261.27 350.0 33.96% 287.40
Commissions
approval for 2012-13 (10% Rise on
Avg. upto Jan., 2012)
Approval for 2010-11 Actual for January,2011 Approval for 2011-12 % Rise of GRIDCO proposal
over 2011-12 actual
The Commission had approved the energy charge for Central Thermal Power Stations for FY 2011-12 considering 20% rise in fuel price of Jan, 2011. But actual energy rate has been increased beyond the approved rate primarily due to rise in coal cost. Comparison of increase in energy charge rate in different central thermal power stations is given below. OERC has approved 10% rise on actual energy charge rate achieved for Jan, 12 for the FY 2012-13 against the 30% rise proposed by GRIDCO.
Energy Charge Rate for Central sector Generating Stations (P/U)
N.B. – Power purchase cost from thermal station consists of fixed cost and variable cost (coal)
(b) Increase in Consumer Price Index:-
All India Consumer Price Index for Industrial Workers, has increased by 6.4% in 2007-08, 9.02% in 2008-09, 12.41% in 2009-10, 10.43% in 2010-11 and 10% in 2011-12 upto January of 2011-12. As per Consumer Price Index for Industrial Workers for Rourkela there has been rise in CPI by 10.48% in 2007-08, 2008-09, 2009-10, 11.37% in 2010-11 and 10.06% in 2011-12 upto January 2012. Taking the said index into account, it has been seen that taking 100 points in 2000-01 as basis has been increased to 198 in Jan, 2012 and assuming 10% rise in the said Index for 2012-13 it would be 218 points in 2012-13 as per All India Consumer Price Index for Industrial Workers and 226 as per CPI for Industrial Workers for Rourkela.
Kutir Jyoti:- As enshrined in clause 5.5.2 of National Electricity Policy 2005, tariff of very poor category of consumers will be at least 50% of average (overall) cost of supply hence it should not be below 230.25 paise as approved average cost of supply is 460.51 paise and as per rise in All India Consumer Price Index for Industrial Workers, it would have been 218 paise and 226 paise based on the consumer price index for Rourkela for the year 2012-13. OERC has decided 200 paise per unit for BPL consumers although NEP stipulates for 230.25 paise at the minimum and as per All India Consumer Price Index for Industrial Workers, it would have been 218 paise and as per CPI for Rourkela it would have been 226 paise to neutralize the rise in CPI.
LT Domestic-0-50 Units:- Considering the rise in All India Consumer Price Index for Industrial Workers, 140 paise in 2000-01 will be 277.20 in Jan, 2012 and 305 paise point in 2012-13. Similarly, if we
28
consider the Consumer Price Index of Rourkela, 140 paise in 2000-01 will be 287 paise in 2012 and 316 paise in 2012-13. However, keeping the honest paying consumers in mind, the Commission has approved 220 paise for domestic consumer having consumption upto 50 units even though as per para 5.5.2 of National Electricity Policy should not be less than 50% of the average cost of supply and 460.51 paise i.e. 230.25 paise and as per All India Consumer Price Index for Industrial Workers, it would have been 305 paise and as per CPI for Rourkela it would have been 316 paise for FY 2012-13.
Consumer price Index (CPI) Vrs Tariff Rise
Year Increase in CPI in
% Index
Domestic Tariff based
on CPI
Actual domestic
tariff upto 50 Units
Agriculture Tariff
based on CPI
Actual Agricultur
e tariff 2000-01 100.0 140.0 140.0 110.0 110.0
2001-02 4.28 104.3 146.0 140.0 114.7 110.0
2002-03 4.10 108.6 152.0 140.0 119.4 110.0
2003-04 3.73 112.6 157.6 140.0 123.9 110.0
2004-05 4.00 117.1 164.0 140.0 128.8 110.0
2005-06 4.23 122.1 170.9 140.0 134.3 110.0
2006-07 2.40 125.0 175.0 140.0 137.5 110.0
2007-08 6.40 133.0 186.2 140.0 146.3 110.0
2008-09 9.02 145.0 203.0 140.0 159.5 110.0
2009-10 12.41 163.0 228.2 140.0 179.3 110.0
2010-11 10.43 180.0 252.0 140.0 198.0 110.0 2011-12 (upto
Jan 2012) 10.00 198.0 277.2 140.0 217.8 110.0
2012-13 (Projected) 10.00 217.8 304.9 220.0 239.6 110.0
CPI Vrs Tariff Rise (Base 2000-01 = 100)
140.0146.0
152.0157.6
164.0170.9 175.0
186.2
203.0
228.2
252.0
277.2
304.9
110 115119
146
159
179
198
218
240
140 140 140 140 140 140 140 140 140 140 140 140
220
110 110 110 110 110 110 110 110 110 110 110122.1 125.0133.0
145.0
163.0
180.0
198.0
104.3 108.6 112.6100.0
217.8
117.1
137134
129124
100.0
150.0
200.0
250.0
300.0
350.0
Index Domestic Tarif f based on CPI Agriculture Tarif f based on CPI Actual domestic tariff upto 50 UnitsActual Agriculture tarif f
9.5 REVENUE REQUIREMENT OF DISCOMS FOR THE FY 2012-13 WESCO NESCO SOUTHCO CESU TOTAL DISCOMs Expenditure Proposed Approved Proposed Approved Proposed Approved Proposed Approved Proposed Approved Cost of Power Purchase 1,948.80 1,597.11 554.55 2149.6 - 6,250.06 Transmission Cost 162.40 132.65 76.18 205.9 - 577.13 SLDC Cost 1.17 0.95 0.55 1.481 - 4.15 Total Power Purchase, Transmission & SLDC Cost (A)
1,866.70 2,112.37 1,640.04 1,730.71 549.29 631.28 2,074.07 2,356.98 6,130.10 6,831.34
Employees cost 286.78 206.82 254.88 180.02 243.43 186.17 349.54 339.89 1,134.63 912.89 Repair & Maintenance Expenses 59.43 40.06 79.860 51.17 57.94 28.28 64.6 57.78 261.83 177.29 Administrative and General Expenses 48.60 29.25 51.01 21.38 42.02 19.17 62.05 39.73 203.68 109.54 Provision for Bad & Doubtful Debts 52.33 16.09 31.58 10.34 18.73 6.92 44.98 19.44 147.62 52.79 Depreciation 39.45 23.13 53.37 31.07 39.08 14.95 88.33 35.38 220.23 104.53 Interest Chargeable to Revenue including Interest on S.D
68.96 37.79 38.59 30.78 32.89 15.98 105.49 53.49 245.93 138.04
Sub-Total 555.55 353.14 509.29 324.75 434.09 271.47 714.99 545.72 2,213.92 1,495.08 Less: Expenses capitalised 2.09 2.09 0.62 0.62 2.66 2.66 5.37 5.37 Total Operation & Maintenance and Other Cost
553.46 351.05 508.67 324.13 431.43 268.81 714.99 545.72 2,208.55 1,489.71
Return on equity 7.78 7.78 10.55 10.55 6.03 6.03 11.64 11.64 36.00 36.00 Total Distribution Cost (B) 561.24 358.83 519.22 334.68 437.46 274.84 726.63 557.36 2,244.55 1,525.71 Amortisation of Regulatory Asset 52.67 73.10 166.49 292.26 - True up of Past Losses 615.42 387.65 215.93 1,219.00 - Contingency reserve 4.13 5.54 4.03 9.00 13.70 9.00 Total Special Appropriation (C) 672.22 - 466.29 - 386.45 9.00 - - 1,524.96 9.00 Total Cost (A+B+C) 3,100.16 2,471.20 2,625.55 2,065.40 1,373.20 915.11 2,800.70 2,914.34 9,899.61 8,366.05 Less: Miscellaneous Receipt 25.16 49.10 17.77 50.70 10.99 17.07 70.44 45.64 124.36 162.51 Total Revenue Requirement 3,075.00 2,422.10 2,607.78 2,014.70 1,362.21 898.04 2,730.26 2,868.70 9,775.25 8,203.55 Expected Revenue (Full year) 1,816.31 2,422.27 1,579.29 2,015.02 624.36 900.32 2249.16 2,870.91 6,269.12 8,208.52 GAP at existing(+/-) (1,258.69) 0.17 (1,028.49) 0.32 (737.85) 2.28 (481.10) 2.21 (3,506.13) 4.97
9.6 RETAIL SUPPLY TARIFF EFFECTIVE FROM 1ST APRIL, 2012
Sl. No. Category of Consumers
Voltage of
Supply
Demand Charge
(Rs./KW/ Month)/
(Rs./KVA/ Month)
Energy Charge
(P/kWh)
Customer Service Charge
(Rs./Month)
Monthly Minimum
Fixed Charge for first KW or part (Rs.)
Monthly Fixed Charge for any additional KW
or part (Rs.)
Rebate (P/kWh)/
DPS
LT Category 1 Domestic 1.a Kutir Jyoti <= 30 Units/month LT FIXED MONTHLY CHARGE--> 60 1.b Others 10 (Consumption <= 50 units/month) LT 220.00 20 15 (Consumption >50, <=200 units/month) LT 390.00 20 15 (Consumption >200, <=400 units/month) LT 490.00 20 15 Consumption >400 units/month) LT 530.00 20 15 2 General Purpose < 110 KVA 10 Consumption <=100 units/month) LT 500.00 30 25 Consumption >100, <=300 units/month) LT 610.00 30 25 (Consumption >300 units/month) LT 680.00 30 25 3 Irrigation Pumping and Agriculture LT 110.00 20 10 10 4 Allied Agricultural Activities LT 120.00 20 10 10 5 Allied Agro-Industrial Activities LT 380.00 80 50 DPS/Rebate 6 Public Lighting LT 530.00 20 15 DPS/Rebate 7 L.T. Industrial (S) Supply <22 KVA LT 530.00 80 35 10
8 L.T. Industrial (M) Supply >=22 KVA <110 KVA LT 530.00 100 50 DPS/Rebate
9 Specified Public Purpose LT 530.00 50 50 DPS/Rebate
10 Public Water Works and Sewerage Pumping<110 KVA LT 530.00 50 50 10
11 Public Water Works and Sewerage Pumping >=110 KVA LT 200 530.00 30 10
12 General Purpose >= 110 KVA LT 200 530.00 30 DPS/Rebate 13 Large Industry LT 200 530.00 30 DPS/Rebate HT Category 14 Bulk Supply - Domestic HT 15 400.00 250 10 15 Irrigation Pumping and Agriculture HT 30 100.00 250 10 16 Allied Agricultural Activities HT 30 110.00 250 10 17 Allied Agro-Industrial Activities HT 50 370.00 250 DPS/Rebate 18 Specified Public Purpose HT 250
As indicated
in the notes below
250 DPS/Rebate 19 General Purpose >70 KVA < 110 KVA HT 250 250 10 20 H.T Industrial (M) Supply HT 250 250 DPS/Rebate 21 General Purpose >= 110 KVA HT 250 250 DPS/Rebate
22 Public Water Works & Sewerage Pumping HT 250 250 10
23 Large Industry HT 250 250 DPS/Rebate 24 Power Intensive Industry HT 250 250 DPS/Rebate 25 Mini Steel Plant HT 250 250 DPS/Rebate 26 Railway Traction HT 250 250 DPS/Rebate 27 Emergency Supply to CGP HT 0 700.00 250 DPS/Rebate 28 Colony Consumption HT 0 450.00 0 DPS/Rebate EHT Category 29 General Purpose EHT 250
As indicated
in the notes below
700 DPS/Rebate 30 Large Industry EHT 250 700 DPS/Rebate 31 Railway Traction EHT 250 700 DPS/Rebate 32 Heavy Industry EHT 250 700 DPS/Rebate 33 Power Intensive Industry EHT 250 700 DPS/Rebate 34 Mini Steel Plant EHT 250 700 DPS/Rebate 35 Emergency Supply to CGP EHT 0 690.00 700 DPS/Rebate 36 Colony Consumption EHT 0 440.00 0 DPS/Rebate
31
Note: Slab rate of energy charges for HT & EHT consumers
(Paise per unit) Load Factor (%) HT EHT
Upto 50% 495 490 > 50% = < 60% 450 445 > 60% 395 390
(i) The reconnection charges w.e.f. 1.4.2012 shall be as follows.
Category of Consumers New Rate Applicable
LT Single Phase Domestic Consumer Rs.150/-
LT Single Phase other consumer Rs.400/-
LT 3 Phase consumers Rs.600/-
All HT & EHT consumers Rs.3000/-
(ii) The meter rents for FY 2012-13 is as follows.
Type of Meter Monthly Meter Rent (Rs.)
1. Single phase electro-magnetic Kwh meter 20
2. Three phase electro-magnetic Kwh meter 40
3. Three phase electro-magnetic tri-vector meter 1000
4. Tri-vector meter for Railway Traction 1000
5. Single phase Static Kwh meter 40
6. Three Phase Static Kwh meter 150
7. Three phase Static Tri-vector meter 1000
8. Three phase Static Bi-vector meter 1000
9. LT Single phase AMR/AMI Compliant meter 50
10. LT Three phase AMR/AMI compliant meter 150
(iii) Prospective small consumers requiring new LT single phase connection upto and including 5
KW load shall only pay a flat charge of Rs.1500/- as service connection charges towards new
connection excluding security deposit as applicable as well as processing fee of Rs.25/-. The
service connection charges include the cost of material and supervision charges.
(iv) A “Tatkal Scheme” for new connection has been introduced which is applicable to LT
Domestic, Agricultural and General Purpose consumers.
(v) In case of installation with static meter/meter with provision of recording demand, the
recorded demand rounded to nearest 0.5 KW shall be considered as the contract demand
requiring no verification irrespective of the agreement. Therefore, for the purpose of
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calculation of Monthly Minimum Fixed Charge (MMFC) for the connected load below 110
KVA, the above shall form the basis.
(vi) The billing demand in respect of consumer with Contract Demand of less than 110 KVA
should be the highest demand recorded in the meter during the Financial Year irrespective of
the Connected Load, which shall require no verification.
(vii) Three phase consumers with static meters are allowed to avail TOD rebate excluding Public
Lighting and emergency supply to CGP @10 paise/unit for energy consumed during off peak
hours. Off peak hours has been defined as 12 Midnight to 6 AM of next day.
(viii) Swajala Dhara consumers under Public Water Works and Sewerage Pumping Installation
category shall get special 10% rebate if electricity bills are paid within due date over and
above normal rebate.
(ix) Drawal by the industries during off-peak hours upto 120% of Contract Demand without levy
of any penalty has been allowed. “Off-peak hours” for the purpose of tariff is defined as from
12 Midnight to 6.00 A.M. of the next day. The consumers who draw beyond their contract
demand during hours other than the off-peak hours shall not be eligible for this benefit. If the
drawal in the off peak hours exceeds 120% of the contract demand, overdrawal penalty shall
be charged over and above the 120% of contract demand. When Statutory Load Regulation is
imposed then restricted demand shall be treated as contract demand.
(x) General purpose consumers with Contract Demand (CD) < 70 KVA shall be treated as LT
consumers for tariff purposes irrespective of level of supply voltage. As per Regulation 76
(1) (c) of OERC Distribution (Conditions of Supply) Code, 2004 the supply for load above 5
KW upto and including 70 KVA shall be in 2-phase, 3-wires or 3-phase, 3 or 4 wires at 400
volts between phases.
(xi) To avail the ‘Take or Pay’ tariff, HT and EHT consumers having contract demand more than
or equal to 110 KVA can give their willingness in writing to pay for energy charge as per
actual drawal or 70% load factor of the contract demand per month whichever is higher upto
the validity of this tariff order. During the validity period no downward revision of the
contract demand shall be allowed. Such HT and EHT consumers shall also be allowed 50 p/u
special concession on total consumption. For calculation of load factor the contract demand
wherever mentioned in KVA the actual power factor shall be taken into consideration. For
Load factor computation allowable interruption hours shall also be taken into consideration.
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(xii) Own Your Transformer – “OYT Scheme” is intended for the existing individual LT
domestic, individual / Group General Purpose consumers who would like to avail single
point HT supply by owning their distribution transformer. In such a case licensee would
extend a special concession of 5% rebate on the total electricity bill (except electricity duty
and meter rent) of the respective category apart from the normal rebate on the payment of the
bill by the due date. If the payment is not made within due date no rebate, either normal or
special is payable. The maintenance of the ‘OYT’ transformer shall be made by DISCOMs.
For removal of doubt it is clarified that the “OYT Scheme” is not applicable to any existing
or new HT/EHT consumer.
(xiii) Power factor incentive for HT & EHT consumers will be applicable above power factor of
97% and power factor penalty shall be applicable below the level of 92%.
The rate of power factor incentive shall be 1% for every 1% rise above the PF of 97% up to
and including 100% on the monthly demand charges and energy charges. Similarly power
factor penalty shall be
i) 0.5% for every 1% fall from 92% upto and including 70% plus ii) 1% for every 1% fall below 70% upto and including 30% plus
iii) 2% for every 1% fall below 30%
There shall not be any power factor penalty for leading power factor.
(xiv) The printout of the record of the static meter relating to MD, PF, number and period of
interruption shall be supplied to the consumer wherever possible with a payment of Rs.500/-
by the consumer for monthly record.
(xv) Tariff as approved shall be applicable in addition to other charges as approved in this Tariff
order w.e.f. 01.04.2012. However, for the month of April, 2012 the pre-revised tariff shall be
applicable if meter reading / billing date is on or before 15.04.2012. The revised tariff shall
be applicable if meter reading/billing date is on 16.04.2012 or afterwards. The billing cycle
as existing shall not be violated by the DISCOMs.